The following tables provide supplementary information in respect of the Group’s oil and gas activities. In the absence of detailed disclosure rules in this area under IFRS, the Group has elected to voluntarily disclose the data that would have been required under the ASC 932 as if it were reporting according to US GAAP.
To the extent that information refers to financial statement data, the information is based on the primary financial statements (IFRS financial statements).
Disclosed financial data refers to the Energy operating business segment excluding gas supply, marketing, trading, and logistics and the Low Carbon Business. Further information on OMV’s operating segments is included in Note 6 – Segment Reporting.
Romania and Black Sea
Austria
Russia
North
South
New Zealand and Australia
Malaysia
Bulgaria and Romania
Austria
Russia (until February 2022)
Norway
Iran (evaluation on hold), Kurdistan Region of Iraq, Libya, Tunisia, United Arab Emirates, YemenIn 2024 OMV and its international JV partner declared their withdrawal from the joint venture in Block S2 and OMV resigned as the operator. (until December 2024)
Australia and New Zealand
SapuraOMVIncluding not only Malaysia but also SapuraOMV subsidiaries in New Zealand, Australia, and Mexico. (until December 2024)
Acquisitions
There were no major acquisitions during 2024, 2023, and 2022.
Disposals and deconsolidation
On December 9, 2024, OMV closed the transaction to sell its 50% share in the Malaysian SapuraOMV Upstream Sdn. Bhd. to TotalEnergies. Further information is included in Note 4 – Significant changes in Group structure.
There were no major disposals during 2023.
On March 1, 2022, OMV ceased to fully consolidate JSC GAZPROM YRGM Development due to the loss of control, following the Russian war on Ukraine.
Non-controlling interest
As OMV holds a 51% share in OMV Petrom, it is fully consolidated. Figures therefore include 100% of OMV Petrom’s assets and results.
OMV had a share of 50% in SapuraOMV and it was fully consolidated; figures therefore include 100% of SapuraOMV’s assets and results until its deconsolidation.
Equity-accounted investments
OMV holds a 10% interest in Pearl Petroleum Company Limited (South).
On March 1, 2022, OMV ceased to equity account its 24.99% interest in OJSC Severneftegazprom (Russia region) due to loss of significant influence, following the Russian war on Ukraine.
The disclosures of equity-accounted investments in the tables below represent the interest of OMV in the companies.
Further information on significant impacts
2023 was significantly impacted by the final investment decision (FID) for the execution of the Neptun Deep project in the Black Sea and the Hail and Ghasha development in the United Arab Emirates.
The subsequent tables may contain rounding differences.
Tables
a) Capitalized costs
Capitalized costs represent the sum of capitalized oil and gas assets, including other intangible assets and property, plant, and equipment such as land, plant and machinery, concessions, licenses, and rights.
In EUR mn |
|
|
|
---|---|---|---|
|
2024 |
2023 |
2022 |
Unproved oil and gas properties |
1,068 |
1,197 |
1,811 |
Proved oil and gas properties |
28,515 |
29,501 |
28,240 |
Total |
29,583 |
30,698 |
30,051 |
Accumulated depreciation |
–20,223 |
–20,009 |
–19,411 |
Net capitalized costs |
9,360 |
10,689 |
10,640 |
In EUR mn |
|
|
|
---|---|---|---|
|
2024 |
2023 |
2022 |
Unproved oil and gas properties |
123 |
116 |
151 |
Proved oil and gas properties |
380 |
344 |
292 |
Total |
504 |
460 |
443 |
Accumulated depreciation |
–214 |
–193 |
–76 |
Net capitalized costs |
290 |
267 |
367 |
b) Costs incurred
Costs incurred include all costs, capitalized or expensed, during the year in the Group’s oil and gas property acquisition, exploration, and development activities.
In EUR mn |
|
|
|
|
|
|
|
|
---|---|---|---|---|---|---|---|---|
|
Romania and Black Sea |
Austria |
Russia |
North |
South |
New Zealand and Australia |
Malaysia |
Total |
|
|
|
|
|
|
|
|
|
|
2024 |
|||||||
Subsidiaries |
|
|
|
|
|
|
|
|
Acquisition of unproved properties |
– |
– |
– |
– |
– |
– |
– |
– |
Exploration costs |
42 |
41 |
– |
74 |
40 |
2 |
29 |
229 |
Development costs |
652 |
48 |
– |
159 |
312 |
15 |
33 |
1,218 |
Costs incurred |
694 |
89 |
– |
233 |
352 |
17 |
61 |
1,447 |
Equity-accounted investments |
– |
– |
– |
– |
14 |
– |
– |
14 |
|
|
|
|
|
|
|
|
|
|
2023 |
|||||||
Subsidiaries |
|
|
|
|
|
|
|
|
Acquisition of unproved properties |
– |
– |
– |
– |
– |
– |
– |
– |
Exploration costs |
35 |
61 |
– |
62 |
28 |
25 |
38 |
248 |
Development costs |
338 |
40 |
– |
168 |
252 |
71 |
154 |
1,024 |
Costs incurred |
373 |
101 |
– |
231 |
280 |
96 |
191 |
1,272 |
Equity-accounted investments |
– |
– |
– |
– |
33 |
– |
– |
33 |
|
|
|
|
|
|
|
|
|
|
2022 |
|||||||
Subsidiaries |
|
|
|
|
|
|
|
|
Acquisition of unproved properties |
– |
– |
– |
– |
– |
– |
– |
– |
Exploration costs |
35 |
24 |
– |
59 |
10 |
26 |
48 |
202 |
Development costs |
327 |
21 |
– |
159 |
171 |
188 |
102 |
969 |
Costs incurred |
362 |
45 |
– |
219 |
181 |
214 |
150 |
1,171 |
Equity-accounted investments |
– |
– |
2 |
– |
27 |
– |
– |
29 |
c) Results of operations of oil and gas producing activities
The following tables represent only those revenues and expenses that occur directly in connection with OMV’s oil and gas producing operations. The results of oil and gas activities should not be equated to Energy net income since interest costs, general corporate overhead costs, other costs, and power production, gas supply, marketing, trading, and logistics, and the Low Carbon Business are not allocated. Further information on OMV’s operating segments is included in Note 6 – Segment Reporting. Income taxes are hypothetically calculated, based on the statutory tax rates and the effect of tax credits on investments and loss carryforwards.
In EUR mn |
|
|
|
|
|
|
|
|
||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Romania and Black Sea |
Austria |
Russia |
North |
South |
New Zealand and Australia |
Malaysia |
Total |
||||||||
|
|
|
|
|
|
|
|
|
||||||||
|
2024 |
|||||||||||||||
Subsidiaries |
|
|
|
|
|
|
|
|
||||||||
Sales to unaffiliated parties1 |
5 |
0 |
– |
766 |
572 |
159 |
257 |
1,759 |
||||||||
Intercompany sales |
2,107 |
382 |
– |
885 |
1,736 |
172 |
– |
5,281 |
||||||||
|
2,112 |
383 |
– |
1,651 |
2,308 |
330 |
257 |
7,041 |
||||||||
Production costs |
–565 |
–89 |
– |
–182 |
–173 |
–78 |
–18 |
–1,104 |
||||||||
Royalties |
–282 |
–80 |
– |
– |
–296 |
–25 |
–9 |
–691 |
||||||||
Exploration expenses2 |
–26 |
–54 |
– |
–46 |
–13 |
–2 |
–10 |
–151 |
||||||||
Depreciation, amortization, impairments, and write-ups |
–639 |
–98 |
– |
–286 |
–389 |
–389 |
–1 |
–1,802 |
||||||||
Other costs3 |
–88 |
–18 |
– |
–120 |
–87 |
–7 |
–24 |
–344 |
||||||||
|
–1,601 |
–339 |
– |
–633 |
–957 |
–501 |
–61 |
–4,092 |
||||||||
Results before income taxes |
511 |
44 |
– |
1,018 |
1,351 |
–170 |
196 |
2,949 |
||||||||
Income taxes4 |
–79 |
1 |
– |
–808 |
–1,224 |
48 |
–63 |
–2,125 |
||||||||
Results from oil and gas production |
432 |
45 |
– |
210 |
127 |
–123 |
132 |
823 |
||||||||
Results of equity-accounted investments |
– |
– |
– |
– |
42 |
– |
– |
42 |
||||||||
|
|
|
|
|
|
|
|
|
||||||||
|
2023 |
|||||||||||||||
Subsidiaries |
|
|
|
|
|
|
|
|
||||||||
Sales to unaffiliated parties1 |
6 |
1 |
– |
979 |
635 |
218 |
268 |
2,107 |
||||||||
Intercompany sales |
2,452 |
418 |
– |
1,064 |
1,646 |
231 |
– |
5,812 |
||||||||
|
2,458 |
419 |
– |
2,044 |
2,282 |
450 |
268 |
7,920 |
||||||||
Production costs |
–535 |
–94 |
– |
–197 |
–181 |
–83 |
–18 |
–1,108 |
||||||||
Royalties |
–501 |
–84 |
– |
– |
–283 |
–46 |
–10 |
–925 |
||||||||
Exploration expenses2 |
–23 |
–8 |
– |
–60 |
–16 |
–8 |
–107 |
–222 |
||||||||
Depreciation, amortization, impairments, and write-ups |
–475 |
–97 |
– |
–333 |
–168 |
–214 |
–72 |
–1,358 |
||||||||
Other costs3 |
–54 |
–17 |
– |
–116 |
–50 |
–15 |
–19 |
–271 |
||||||||
|
–1,587 |
–300 |
– |
–707 |
–698 |
–367 |
–226 |
–3,884 |
||||||||
Results before income taxes |
871 |
119 |
– |
1,337 |
1,584 |
83 |
42 |
4,036 |
||||||||
Income taxes4 |
–124 |
–42 |
– |
–1,063 |
–1,273 |
–23 |
–16 |
–2,542 |
||||||||
Results from oil and gas production |
746 |
76 |
– |
274 |
311 |
60 |
26 |
1,493 |
||||||||
Results of equity-accounted investments |
– |
– |
– |
– |
–72 |
– |
– |
–72 |
||||||||
|
|
|
|
|
|
|
|
|
||||||||
|
2022 |
|||||||||||||||
Subsidiaries |
|
|
|
|
|
|
|
|
||||||||
Sales to unaffiliated parties1 |
5 |
–32 |
206 |
1,394 |
931 |
225 |
302 |
3,032 |
||||||||
Intercompany sales |
3,281 |
959 |
– |
3,530 |
1,927 |
236 |
– |
9,933 |
||||||||
|
3,286 |
927 |
206 |
4,924 |
2,858 |
461 |
302 |
12,965 |
||||||||
Production costs |
–512 |
–91 |
– |
–183 |
–183 |
–87 |
–16 |
–1,071 |
||||||||
Royalties |
–1,102 |
–182 |
– |
– |
–312 |
–46 |
–21 |
–1,663 |
||||||||
Exploration expenses2 |
–28 |
–12 |
– |
–118 |
2 |
–53 |
–41 |
–250 |
||||||||
Depreciation, amortization, impairments, and write-ups |
–845 |
–43 |
–12 |
–416 |
–424 |
46 |
–91 |
–1,785 |
||||||||
Other costs3 |
–65 |
–15 |
–60 |
–131 |
–64 |
–2 |
–22 |
–359 |
||||||||
|
–2,552 |
–344 |
–72 |
–848 |
–980 |
–142 |
–191 |
–5,128 |
||||||||
Results before income taxes |
734 |
583 |
135 |
4,077 |
1,878 |
319 |
111 |
7,837 |
||||||||
Income taxes4 |
–121 |
–229 |
–28 |
–3,274 |
–1,553 |
–83 |
–34 |
–5,322 |
||||||||
Results from oil and gas production |
613 |
354 |
107 |
803 |
325 |
237 |
77 |
2,516 |
||||||||
Results of equity-accounted investments |
– |
– |
3 |
– |
56 |
– |
– |
59 |
||||||||
|
d) Oil and gas reserve quantities
Proved reserves are those quantities of oil and gas that, through analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain. Proved oil and gas reserves were estimated based on a twelve-month average price, unless prices are defined by contractual arrangements.
Proved developed reserves are those proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods, or in which the costs of the required equipment are relatively minor compared with the cost of a new well, and through installed extraction equipment and infrastructure operational at the time of the reserves estimate. It should be reasonably certain that the required future expenditure will be made to safeguard existing equipment within the current budget.
Proved undeveloped reserves are those proved reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where relatively major expenditure is required for recompletion, or substantial new investment is required in order to safeguard or replace aging facilities.
In mn bbl |
|
|
|
|
|
|
|
|
---|---|---|---|---|---|---|---|---|
|
Romania and Black Sea |
Austria |
Russia |
North |
South |
New Zealand and Australia |
Malaysia |
Total |
Proved developed and undeveloped reserves – Subsidiaries |
||||||||
January 1, 2022 |
258.8 |
31.4 |
– |
46.4 |
275.7 |
12.9 |
6.5 |
631.7 |
Revisions of previous estimates |
–8.4 |
1.9 |
– |
15.8 |
32.3 |
1.1 |
0.4 |
43.1 |
Purchases |
– |
– |
– |
– |
– |
– |
– |
– |
Disposals |
– |
– |
– |
– |
– |
– |
– |
– |
Extensions and discoveries |
0.1 |
– |
– |
– |
– |
– |
– |
0.1 |
Production |
–20.9 |
–3.3 |
– |
–14.7 |
–27.3 |
–3.0 |
–0.6 |
–69.9 |
December 31, 2022 |
229.6 |
30.0 |
– |
47.6 |
280.6 |
11.0 |
6.2 |
605.0 |
Revisions of previous estimates |
–1.6 |
0.7 |
– |
6.9 |
89.9 |
0.6 |
2.1 |
98.6 |
Purchases |
– |
– |
– |
– |
– |
– |
– |
– |
Disposals |
– |
– |
– |
– |
– |
– |
– |
– |
Extensions and discoveries |
0.3 |
– |
– |
– |
– |
– |
– |
0.3 |
Production |
–20.0 |
–3.0 |
– |
–13.4 |
–29.1 |
–3.6 |
–0.7 |
–69.7 |
December 31, 2023 |
208.3 |
27.7 |
– |
41.1 |
341.5 |
8.0 |
7.6 |
634.2 |
Revisions of previous estimates |
–1.8 |
1.1 |
– |
3.8 |
13.7 |
0.0 |
0.0 |
16.9 |
Purchases |
– |
– |
– |
– |
– |
– |
– |
– |
Disposals |
– |
– |
– |
– |
–4.4 |
– |
–6.9 |
–11.3 |
Extensions and discoveries |
0.2 |
– |
– |
– |
– |
– |
– |
0.2 |
Production |
–19.1 |
–3.0 |
– |
–10.0 |
–29.5 |
–2.9 |
–0.8 |
–65.2 |
December 31, 2024 |
187.6 |
25.8 |
– |
35.0 |
321.3 |
5.1 |
– |
574.8 |
|
|
|
|
|
|
|
|
|
Proved developed and undeveloped reserves – Equity-accounted investments |
||||||||
December 31, 2022 |
– |
– |
– |
– |
16.0 |
– |
– |
16.0 |
December 31, 2023 |
– |
– |
– |
– |
15.1 |
– |
– |
15.1 |
December 31, 2024 |
– |
– |
– |
– |
15.7 |
– |
– |
15.7 |
|
|
|
|
|
|
|
|
|
Proved developed reserves – Subsidiaries |
||||||||
December 31, 2022 |
206.6 |
30.0 |
– |
39.4 |
234.5 |
9.2 |
1.7 |
521.4 |
December 31, 2023 |
187.6 |
27.7 |
– |
32.8 |
252.4 |
8.0 |
1.4 |
509.8 |
December 31, 2024 |
171.1 |
25.8 |
– |
23.6 |
245.3 |
4.8 |
– |
470.6 |
|
|
|
|
|
|
|
|
|
Proved developed reserves – Equity-accounted investments |
||||||||
December 31, 2022 |
– |
– |
– |
– |
15.4 |
– |
– |
15.4 |
December 31, 2023 |
– |
– |
– |
– |
13.4 |
– |
– |
13.4 |
December 31, 2024 |
– |
– |
– |
– |
14.8 |
– |
– |
14.8 |
In bcf |
|
|
|
|
|
|
|
|
||
---|---|---|---|---|---|---|---|---|---|---|
|
Romania and Black Sea |
Austria |
Russia |
North |
South |
New Zealand and Australia |
Malaysia |
Total |
||
Proved developed and undeveloped reserves – Subsidiaries |
||||||||||
January 1, 2022 |
865.5 |
152.4 |
– |
289.2 |
145.8 |
274.2 |
514.7 |
2,241.7 |
||
Revisions of previous estimates |
68.1 |
15.2 |
– |
144.4 |
–1.3 |
9.0 |
–7.9 |
227.6 |
||
Purchases |
– |
– |
– |
– |
– |
– |
– |
– |
||
Disposals |
– |
– |
– |
– |
– |
– |
– |
– |
||
Extensions and discoveries |
1.6 |
– |
– |
– |
– |
– |
– |
1.6 |
||
Production |
–122.0 |
–19.7 |
– |
–102.2 |
–14.7 |
–47.1 |
–60.0 |
–365.6 |
||
December 31, 20221 |
813.2 |
147.9 |
– |
331.4 |
129.8 |
236.1 |
446.8 |
2,105.2 |
||
Revisions of previous estimates |
464.3 |
13.7 |
– |
37.0 |
195.5 |
–36.5 |
56.2 |
730.1 |
||
Purchases |
– |
– |
– |
– |
– |
– |
– |
– |
||
Disposals |
– |
– |
– |
– |
– |
– |
– |
– |
||
Extensions and discoveries |
4.9 |
– |
– |
– |
– |
– |
– |
4.9 |
||
Production |
–115.7 |
–18.0 |
– |
–84.5 |
–13.6 |
–53.8 |
–57.9 |
–343.6 |
||
December 31, 20231 |
1,166.8 |
143.6 |
– |
283.9 |
311.7 |
145.7 |
445.0 |
2,496.7 |
||
Revisions of previous estimates |
65.9 |
20.3 |
– |
49.5 |
6.6 |
–35.4 |
1.8 |
108.7 |
||
Purchases |
– |
– |
– |
– |
– |
– |
– |
– |
||
Disposals |
– |
– |
– |
– |
– |
– |
–389.9 |
–389.9 |
||
Extensions and discoveries |
1.9 |
– |
– |
– |
– |
– |
– |
1.9 |
||
Production |
–112.4 |
–18.2 |
– |
–86.1 |
–9.2 |
–36.0 |
–56.9 |
–318.9 |
||
December 31, 20241 |
1,122.3 |
145.7 |
– |
247.2 |
309.1 |
74.3 |
– |
1,898.5 |
||
|
|
|
|
|
|
|
|
|
||
Proved developed and undeveloped reserves – Equity-accounted investments |
||||||||||
December 31, 2022 |
– |
– |
– |
– |
303.6 |
– |
– |
303.6 |
||
December 31, 2023 |
– |
– |
– |
– |
292.5 |
– |
– |
292.5 |
||
December 31, 2024 |
– |
– |
– |
– |
307.8 |
– |
– |
307.8 |
||
|
|
|
|
|
|
|
|
|
||
Proved developed reserves – Subsidiaries |
||||||||||
December 31, 2022 |
723.4 |
80.3 |
– |
290.8 |
39.9 |
195.9 |
228.9 |
1,559.1 |
||
December 31, 2023 |
628.0 |
76.0 |
– |
246.8 |
35.0 |
145.7 |
158.5 |
1,290.0 |
||
December 31, 2024 |
621.2 |
74.9 |
– |
203.9 |
39.5 |
56.1 |
– |
995.6 |
||
|
|
|
|
|
|
|
|
|
||
Proved developed reserves – Equity-accounted investments |
||||||||||
December 31, 2022 |
– |
– |
– |
– |
288.3 |
– |
– |
288.3 |
||
December 31, 2023 |
– |
– |
– |
– |
259.3 |
– |
– |
259.3 |
||
December 31, 2024 |
– |
– |
– |
– |
268.8 |
– |
– |
268.8 |
||
|
e) Standardized measure of discounted future net cash flows
The future net cash flow information is based on the assumption that the prevailing economic and operating conditions will persist throughout the time during which proved reserves will be produced. Neither the effects of future pricing changes nor expected changes in technology and operating practices are considered.
Future cash inflows represent the revenues received from production volumes, including cushion gas held in storage reservoirs, assuming that the future production is sold at prices used in estimating year-end quantities of proved reserves (twelve-month average price). Future production costs include the estimated expenditure for production of the proved reserves plus any production taxes without consideration of future inflation. Future decommissioning costs comprise the net costs associated with decommissioning wells and facilities. Future development costs include the estimated costs of development drilling and installation of production facilities. For all three categories, year-end costs without consideration of inflation are assumed. Future income tax payments are calculated on the basis of the income tax rate applicable in each of the countries in which the Group operates. The present cash value results from the discounting of the future net cash flow at a discount rate of 10% per year. The standardized measure does not purport to be an estimate of the fair value of the Group’s proven reserves. An estimate of fair value would also take into account, among many other factors, the expected recovery of reserves in excess of proved reserves, anticipated changes in future prices and costs, and a discount factor representative of the risks inherent in the production of oil and gas.
In EUR mn |
|
|
|
|
|
|
|
|
---|---|---|---|---|---|---|---|---|
|
Subsidiaries and equity-accounted investments |
|
||||||
|
Romania and Black Sea |
Austria |
Russia |
North |
South |
New Zealand and Australia |
Malaysia |
Total |
|
|
|
|
|
|
|
|
|
|
2024 |
|||||||
Subsidiaries |
|
|
|
|
|
|
|
|
Future cash inflows |
21,487 |
3,154 |
– |
4,798 |
24,536 |
704 |
– |
54,679 |
Future production and decommissioning costs |
–12,668 |
–2,071 |
– |
–2,240 |
–7,589 |
–1,227 |
– |
–25,795 |
Future development costs |
–2,652 |
–335 |
– |
–579 |
–1,551 |
–78 |
– |
–5,195 |
Future net cash flows, |
6,167 |
748 |
– |
1,979 |
15,395 |
–601 |
– |
23,689 |
Future income taxes |
–783 |
–94 |
– |
–1,924 |
–10,831 |
191 |
– |
–13,442 |
Future net cash flows, |
5,384 |
654 |
– |
55 |
4,564 |
–410 |
– |
10,247 |
10% annual discount for estimated timing of cash flows |
–1,864 |
–353 |
– |
26 |
–2,237 |
167 |
– |
–4,261 |
Standardized measure of discounted future net cash flows |
3,519 |
301 |
– |
81 |
2,327 |
–243 |
– |
5,986 |
Equity-accounted investments |
– |
– |
– |
– |
370 |
– |
– |
370 |
|
|
|
|
|
|
|
|
|
|
2023 |
|||||||
Subsidiaries |
|
|
|
|
|
|
|
|
Future cash inflows |
30,238 |
3,656 |
– |
6,457 |
28,233 |
1,170 |
2,256 |
72,011 |
Future production and decommissioning costs |
–13,937 |
–2,276 |
– |
–2,397 |
–8,842 |
–1,412 |
–622 |
–29,486 |
Future development costs |
–3,184 |
–378 |
– |
–512 |
–1,901 |
–86 |
–71 |
–6,131 |
Future net cash flows, |
13,117 |
1,002 |
– |
3,549 |
17,491 |
–327 |
1,563 |
36,395 |
Future income taxes |
–1,857 |
–129 |
– |
–3,265 |
–12,340 |
168 |
–461 |
–17,884 |
Future net cash flows, |
11,260 |
873 |
– |
284 |
5,150 |
–159 |
1,103 |
18,511 |
10% annual discount for estimated timing of cash flows |
–4,546 |
–422 |
– |
–11 |
–2,582 |
169 |
–297 |
–7,689 |
Standardized measure of discounted future net cash flows |
6,714 |
451 |
– |
273 |
2,568 |
10 |
806 |
10,821 |
Equity-accounted investments |
– |
– |
– |
– |
475 |
– |
– |
475 |
|
|
|
|
|
|
|
|
|
|
2022 |
|||||||
Subsidiaries |
|
|
|
|
|
|
|
|
Future cash inflows |
29,864 |
7,435 |
– |
14,937 |
26,611 |
2,051 |
2,248 |
83,145 |
Future production and decommissioning costs |
–15,951 |
–2,766 |
– |
–2,711 |
–7,771 |
–1,829 |
–690 |
–31,718 |
Future development costs |
–1,424 |
–246 |
– |
–631 |
–890 |
–222 |
–213 |
–3,626 |
Future net cash flows, |
12,489 |
4,422 |
– |
11,594 |
17,950 |
0 |
1,345 |
47,800 |
Future income taxes |
–1,724 |
–1,028 |
– |
–10,465 |
–13,283 |
132 |
–380 |
–26,748 |
Future net cash flows, |
10,765 |
3,394 |
– |
1,129 |
4,667 |
132 |
965 |
21,053 |
10% annual discount for estimated timing of cash flows |
–4,718 |
–1,815 |
– |
–184 |
–1,547 |
213 |
–296 |
–8,347 |
Standardized measure of discounted future net cash flows |
6,048 |
1,579 |
– |
945 |
3,120 |
345 |
669 |
12,705 |
Equity-accounted investments |
– |
– |
– |
– |
451 |
– |
– |
451 |
f) Changes in the standardized measure of discounted future net cash flows
In EUR mn |
|
|
|
||||
---|---|---|---|---|---|---|---|
|
2024 |
2023 |
2022 |
||||
Subsidiaries |
|
|
|
||||
Beginning of year |
10,821 |
12,705 |
7,373 |
||||
Oil and gas sales produced during the year, net of related production costs |
–4,714 |
–7,049 |
–4,102 |
||||
Net change in prices and production costs related to future periods |
–4,427 |
–6,538 |
13,243 |
||||
Net change due to purchases and sales of minerals in place1 |
–684 |
– |
– |
||||
Net change due to extensions and discoveries |
9 |
32 |
7 |
||||
Development and decommissioning costs incurred during the period |
1,369 |
823 |
895 |
||||
Changes in estimated future development and decommissioning costs |
–436 |
–1,912 |
–344 |
||||
Revisions of previous reserve estimates |
293 |
4,239 |
4,507 |
||||
Accretion of discount |
1,011 |
1,146 |
671 |
||||
Net change in income taxes (incl. tax effects from purchases and sales) |
2,908 |
7,539 |
–9,593 |
||||
Other2 |
–165 |
–165 |
48 |
||||
End of year |
5,986 |
10,821 |
12,705 |
||||
Equity-accounted investments |
370 |
475 |
451 |
||||
|
Vienna, March 14, 2025
The Executive Board
Alfred Stern m.p.
Chairman of the Executive Board
and Chief Executive Officer
Reinhard Florey m.p.
Chief Financial Officer
Martijn van Koten m.p.
Executive Vice President Fuels & Feedstock and
Executive Vice President Chemicals
Berislav Gaso m.p.
Executive Vice President Energy